Process and apparatus for recovering olefins

ABSTRACT

The present invention relates to a process and apparatus for recovering product from reactor effluent of a reactor for a hydrocarbon feedstream. An indigenous C 4  stream is used as lean oil in a demethanizer, which facilitates significant cost and operational savings. C 4  bottoms from a downstream depropanizer is used as lean oil recycle.

BACKGROUND OF THE INVENTION

Olefins find widespread uses in many industries. For example, they represent the basic building blocks in such diverse uses as film and packaging, communications, construction, automotive and home appliances. These important materials are generally produced by the cracking of a hydrocarbon feedstream, which converts saturated hydrocarbons present in the feedstream into olefins.

Current cracking technologies for the production of light olefins (e.g. ethylene, propylene and, optionally, butylenes), gasoline and other cracked products such as light paraffins and naphtha can be classified into the two categories of thermal cracking (also known as steam cracking) and catalytic cracking. These technologies have been practiced for many years and are considered the workhorses for light-olefin production.

Steam or thermal cracking, a robust technology that does not utilize catalyst, produces the more valuable ethylene as the primary light olefin product. It is particularly suitable for cracking paraffinic feedstocks to a wide range of products including hydrogen, light olefins, light paraffins, and heavier liquid hydrocarbon products such as pyrolysis gasoline, steam cracked gas oil, etc. Conventional steam cracking utilizes a pyrolysis furnace, which has two main sections: a convection section and a radiant section reaction zone.

The hydrocarbon feed typically enters the convection section of the furnace as a liquid (except for light feeds which enter as a vapor) wherein it is typically heated and vaporized by indirect contact with hot flue gas from the radiant section and by mixing with steam. The vaporized feed and steam mixture is then introduced into the radiant section where the cracking takes place.

Current catalytic cracking technologies employ solid acid catalysts such as zeolites to promote cracking reactions. Unlike steam cracking technology, propylene is the primary light olefin product of catalytic cracking. Accordingly, catalytic cracking would be considered as the main source for growing propylene demand.

Cracked gases typically comprise hydrogen, carbon monoxide, carbon dioxide, methane, acetylene, ethylene, ethane, methyl acetylene, propadiene, propylene, propane, butadienes, butanes, butenes, C₅ hydrocarbons, C₆-C₈ hydrocarbons, non-aromatics, benzene, toluene and other heavy hydrocarbons. These gases including olefins leave the pyrolysis furnace for further downstream processing. It is necessary to separate the useful olefins, e.g., ethylene and propylene, from the rest of the product gases.

A widely practiced method for separating the product gases into various fractions involves compression, drying and fractional distillation. Typically, the product gases are compressed in multi-stage compression units wherein some heavier hydrocarbons and water are separated. The remaining product gases are then dried and chilled to separate lighter hydrocarbon fractions, e.g., ethylene and propylene, from heavier hydrocarbons. Chilling makes extensive use of ethylene and propylene refrigeration systems.

A major drawback related to the operation of the above-described olefin recovery plants relates to high-energy demands. Compression, ethylene refrigeration and propylene refrigeration are major contributors to this energy consumption.

Another method used in separating the product gases into various fractions involves the use of an absorber solvent to remove a target fraction from the remaining product gases. For example, in a demethanizer absorber, product gases containing methane typically flow upwardly within a tower in countercurrent contact with a downwardly flowing lean absorber solvent. The absorber solvent absorbs the methane from the remaining hydrocarbons in the product gases and typically exits the bottoms of the tower as (methane) rich absorber solvent. One drawback related to the use of such an absorber solvent system is that the rich absorber solvent typically contains a small, but valuable amount of desired product (e.g., ethylene) in addition to the unwanted methane. Huge expense and added operating costs can be incurred in downstream separation equipment required to separate the wanted (e.g., ethylene) products from the rich absorber solvent.

SUMMARY OF THE INVENTION

According to one aspect of the present invention a process comprises:

-   -   (i) reacting a hydrocarbon feedstream to produce a reactor         effluent comprising C₁-C₄ ⁺ hydrocarbons;     -   (ii) separating a C₄ hydrocarbon stream from the reactor         effluent;     -   (iii) contacting a hydrocarbon fraction from the reactor         effluent with an absorber medium in an absorber demethanizer         wherein methane is separated from the hydrocarbon fraction; and     -   (iv) wherein at least a first portion of the absorber medium         comprises the C₄ hydrocarbon stream that has been separated from         the reactor effluent.

Preferably, the C₄ hydrocarbon stream is separated from the reactor effluent by separating the reactor effluent into a C₄ ⁻ stream and a C₅ ⁺ stream; and separating the C₄ ⁻ stream into a C₄ stream and a C₃ ⁻ stream. Also preferably, the C₃ ⁻ stream comprises the hydrocarbon fraction from the reactor effluent that is contacted with absorber medium in the absorber demethanizer. In a preferred aspect of the present invention, the process is performed in the absence of ethylene refrigeration. In another preferred aspect, the hydrocarbon feedstream is reacted in a propylene catalytic cracker.

In a preferred aspect of the present invention, at least a second portion of the absorber medium comprises a C₄ hydrocarbon recycle stream from downstream processing. Preferably, the downstream processing comprises separation of the C₄ hydrocarbon from a hydrocarbon mixture.

According to another aspect of the invention, the reactor effluent is separated into the C₄ ⁻ stream and the C₅ ⁺ stream in a debutanizer. Preferably, the C₄ ⁻ stream comprises an overhead stream from the debutanizer and the C₅ ⁺ stream comprises a bottoms stream from the debutanizer.

According to a further aspect of the present invention, a C₂-C₄ stream exits the demethanizer and is fed to a deethanizer wherein C₂ hydrocarbon(s) are separated from the C₂-C₄ stream. Preferably, the C₂-C₄ stream exits as bottoms and the methane exits as overhead from the demethanizer.

In another aspect of the present invention, a C₃-C₄ stream exits the deethanizer and is fed to a depropanizer wherein C₃ hydrocarbon(s) are separated from the C₃-C₄ stream. Preferably, the C₃-C₄ stream exits as bottoms and the C₃ hydrocarbon(s) exit as overhead from the deethanizer.

In still another aspect of the present invention, C₄ hydrocarbon(s) are removed from the depropanizer as a stream that is recycled to the demethanizer as the at least second portion of the absorber medium.

According to another aspect of the present invention a process comprises:

-   -   (i) catalytically cracking a hydrocarbon feedstream to produce         an olefinic reactor effluent;     -   (ii) fractionating the olefinic reactor effluent in a primary         fractionator into a primary fractionator overhead stream and a         primary fractionator bottoms stream;     -   (iii) feeding the primary fractionator overhead stream to a         dubutanizer, wherein the overhead stream is separated into a C₄         ⁻ overhead stream and a C₅ ⁺ bottoms stream;     -   (iv) compressing and cooling the C₄ ⁻ overhead stream;     -   (v) separating the compressed and cooled C₄ ⁻ overhead stream         into a C₄ stream and a C₃ ⁻ stream;     -   (vi) feeding the C₄ stream to a first location of an absorber         demethanizer;     -   (vii) feeding the C₃ ⁻ stream to the absorber demethanizer at a         C₃ ⁻ stream feed location that is below the first location;     -   (viii) separating methane from the C₃ ⁻ stream as overhead in         the demethanizer;     -   (ix) removing a C₂-C₄ stream from the demethanizer as bottoms;     -   (x) feeding the C₂-C₄ stream from the demethanizer to a         deethanizer, wherein the C₂-C₄ stream is separated into a C₂         overhead stream and a C₃-C₄ bottoms stream;     -   (xi) feeding the C₃-C₄ bottoms stream to a depropanizer, wherein         the C₃-C₄ bottoms stream is separated into a C₃ overhead stream         and a C₄ bottoms stream; and     -   (xii) feeding at least a portion of the C₄ bottoms stream to the         absorber demethanizer at a location above the C₃ ⁻ stream feed         location.

In yet another aspect of the invention, apparatus comprises:

-   -   (i) a debutanizer comprising an upper debutanizer overhead         outlet and a lower debutanizer bottoms outlet;     -   (ii) an absorber demethanizer downstream of the debutanizer and         in fluid flow communication therewith through the debutanizer         overhead outlet, the absorber demethanizer comprising an upper         demethanizer overhead outlet, a lower demethanizer bottoms         outlet, a liquid absorber medium inlet and a gaseous hydrocarbon         inlet located below the absorber medium inlet;     -   (iii) a deethanizer downstream of the absorber demethanizer and         having a feed inlet in fluid flow communication with the         demethanizer bottoms outlet, the deethanizer comprising an upper         deethanizer overhead outlet and a lower deethanizer bottoms         outlet; and     -   (iv) a depropanizer downstream of the deethanizer and having a         feed inlet in fluid flow communication with the deethanizer         bottoms outlet, the depropanizer comprising an upper         depropanizer overhead outlet and a lower depropanizer bottoms         outlet, the depropanizer bottoms outlet being in fluid flow         communication with the demethanizer through a liquid absorber         medium inlet located above the demethanizer gaseous hydrocarbon         inlet.

Preferably, the apparatus further comprises a compressor in fluid flow communication with the debutanizer overhead outlet, a heat exchanger in fluid flow communication with the compressor and a separator in fluid flow communication with the heat exchanger, the separator having a gaseous hydrocarbon outlet in fluid flow communication with the demethanizer gaseous hydrocarbon inlet and a liquid outlet in fluid flow communication with the demethanizer liquid absorber medium inlet.

BRIEF DESCRIPTION OF THE DRAWING

The FIGURE represents a schematic flow diagram providing a non-limiting illustration of a process and apparatus in accordance with the present invention.

DETAILED DESCRIPTION OF THE INVENTION

The particulars shown herein are by way of example and for purposes of illustrative discussion of the embodiments of the present invention only and are presented to provide what is believed to be the most useful and readily understood description of the principles and conceptual aspects of the present invention. In this regard, no attempt is made to show structural details of the present invention in more detail than is necessary for the fundamental understanding of the present invention, the description making apparent to those skilled in the art how the several forms of the present invention may be embodied in practice.

As is well known and within the skill of the art, when reference is made to a specific hydrocarbon stream, e.g., a C₄ stream, it is not practical or intended that such reference is strictly limited to a pure C₄ stream, since other components, albeit in small amounts, will also be present (e.g., C₃ will be present in a small amount in a stream designated as a C₄ stream). Accordingly, such reference is intended to include small amounts of other hydrocarbons.

With particular reference to the FIGURE, reference numeral 1 refers to a hydrocarbon feedstream from a reactor. As already indicated above, the reactor typically comprises a steam cracker or a catalytic cracker.

The hydrocarbons reacted in the reactor could comprise, by way of non-limiting example, hydrocarbonaceous oils boiling in the range of about 221° C. to about 566° C., such as gas oil, steam cracked gas oil and residues; heavy hydrocarbonaceous oils comprising materials boiling above 566° C.; heavy and reduced petroleum crude oil, petroleum atmospheric distillation bottoms, petroleum vacuum distillation bottoms, heating oil, pitch, asphalt, bitumen, other heavy hydrocarbon residues, tar sand oils, shale oil, liquid products derived from coal liquefaction processes, and mixtures therefore. Other non-limiting feedstreams could comprise steam heating oil, jet fuel, diesel, kerosene, gasoline, coker naphtha, steam cracked naphtha, catalytically cracked naphtha, hydrocrackate, reformate, raffinate reformate, Fischer-Tropsch liquids, Fischer-Tropsch gases, natural gasoline, distillate, virgin naphtha, C₅₊ olefins (i.e., C₅ olefins and above), C₅₊ paraffins, ethane, propane, butanes, butenes and butadiene, cat-cracked naphtha, coker naphtha, steam cracked gas oil, olefinic Fischer-Tropsch, virgin naphtha, natural gasoline, reformate and raffinate.

A propylene catalytic cracker using a fluidized bed (known within the art) is the preferred reactor. Naphtha is a preferred feedstock for treatment in the propylene catalytic cracker. As indicated above, the hydrocarbon feedstream 1 could typically comprise hydrogen, carbon monoxide, carbon dioxide, methane, acetylene, ethylene, ethane, methyl acetylene, propadiene, propylene, propane, butadienes, butanes, butenes, C₅ hydrocarbons, C₆-C₈ hydrocarbons, non-aromatics, benzene, toluene and other heavy hydrocarbons.

Reference numeral 2 refers to a primary fractionator to which feedstream 1 is fed for separation into, for example, a C₆ ⁺ stream (C₆ hydrocarbons and higher) and a C₅ ⁻ stream (C₅ hydrocarbons and lower). The C₆ ⁺ stream exits the primary fractionator as liquid bottoms 4, and the C₅ ⁻ stream exits primary fractionator 2 as gaseous overhead. As illustrated, the C₅ ⁻ gaseous overhead stream 3 is compressed in series compressors 5 and 6, with intercooling in heat exchangers 7 and 8 before entering debutanizer 9. Debutanizer 9, preferably, is a distillation tower containing, for example, packing (e.g. raschig rings) or trays (e.g., bubble or sieve trays) to promote intimate contact between rising vapor and falling liquid within the debutanizer. The debutanizer separates the C₅ ⁻ stream into a C₄ ⁻ gaseous overhead stream 10 and a C₅ liquid bottoms stream.

Reference numeral 11 refers to a compressor for C₄ ⁻ compression before cooling in heat exchanger 12. The compressed and cooled C₄ ⁻ stream flows to vessel 13 wherein a C₄ stream 14 is separated from a C₃ ⁻ stream 15. As shown, C₃ ⁻ stream 15 is fed as a gas to absorber demethanizer 16 at a first location 17. C₄ stream 14 is fed to absorber demethanizer 16 at a second location 18 that is located above feed location 17 for the C₃ ⁻ stream 15. At this point, the C₄ stream at feed location 18 comprises at least a first portion of the absorber medium (lean oil/solvent) for the absorber demethanizer. As will be more fully described below, in a preferred embodiment, C₄ stream 15 is combined with a recycle C₄ stream from the downstream depropanizer for use in the absorber demethanizer. Absorber demethanizer 16, preferably, is a distillation tower containing, for example, packing (e.g. raschig rings) or trays (e.g., bubble or sieve trays) to promote intimate contact between rising vapor and falling liquid within the absorber demethanizer.

Within absorber demethanizer 16, the C₄ stream flows downwardly in countercurrent contact with upwardly flowing C₃ ⁻ stream entering at feed location 17. The C₄ stream, acting as absorber medium, absorbs C₂ and C₃ hydrocarbons from the C₃ ⁻. Thus, methane exits absorber demethanizer as overhead 19, and C₂-C₄ hydrocarbons exit as liquid bottoms 20. Bottoms stream 20 is fed to a deethanizer 23 at feed location 24. Well-known reflux and reboiler installations are schematically illustrated at 21 and 22, respectively, in the FIGURE.

The deethanizer, preferably, is a distillation tower containing, for example, packing (e.g. raschig rings) or trays (e.g., bubble or sieve trays). Within deethanizer 23, C₂ hydrocarbons are separated from C₃-C₄ hydrocarbons. The C₂ hydrocarbons exit tower 23 as overhead 25, and the C₃-C₄ hydrocarbons exit as bottoms 26. Well-known reflux and reboiler installations are generally indicated at 27 and 28 in the FIGURE. Bottoms stream 26 is fed to depropanizer 29. The depropanizer, preferably, is a distillation tower containing, for example, packing (e.g. raschig rings) or trays (e.g., bubble or sieve trays). Within depropanizer 29, C₃ hydrocarbons are separated from C₄ hydrocarbons. The C₃ hydrocarbons exit the depropanizer as overhead 30 and the C₄ hydrocarbons exit therefrom as bottoms 31. The C₄ bottoms 31 are then recycled, with compression, pumping and cooling (not shown) as necessary, to demethanizer 16 as the remaining portion of the absorber medium.

As will occur to those of ordinary skill in the art having the benefit of the above disclosure, in using processes and apparatus in accordance with the present invention, many advantages can be realized by practicing the various aspects and embodiments of the invention. For example, using the illustrated olefins recovery scheme permits the elimination of ethylene refrigeration and the reduction of propylene refrigeration. Also, significant steam savings (used, for example to drive ethylene refrigeration compressors), relative to existing technologies, can be realized. Further for example, placing the debutanizer first in the recovery scheme facilitates the use of an indigenous stream as lean oil (absorber medium). By using an indigenous hydrocarbon fraction as the absorber medium, loss of prime product (e.g., propylene) is reduced or minimized as compared to use of alternative absorption technologies, and potential for product contamination is significantly less than absorption technologies using non-indigenous lean oil.

One of ordinary skill in the art, having the benefit of the present disclosure, will appreciate that many modifications may be made to the various aspects and embodiments of the present invention as described herein without departing from the spirit of the present invention. Accordingly, the various aspects and embodiments described herein are illustrative only and are not intended to limit the scope of the present invention. 

1. A process comprising: (i) reacting a hydrocarbon feedstream to produce a reactor effluent comprising C₁-C₄ ⁺ hydrocarbons; (ii) separating a C₄ hydrocarbon stream from the reactor effluent; (iii) contacting a hydrocarbon fraction from the reactor effluent with an absorber medium in an absorber demethanizer wherein methane is separated from the hydrocarbon fraction; and (iv) wherein at least a first portion of the absorber medium comprises the C₄ hydrocarbon stream that has been separated from the reactor effluent.
 2. The process of claim 1, wherein the C₄ hydrocarbon stream is separated from the reactor effluent by separating the reactor effluent into a C₄ ⁻ stream and a C₅ ⁺ stream; and separating the C₄ ⁻ stream into a C₄ stream and a C₃ ⁻ stream.
 3. The process of claim 2, wherein the reactor effluent is separated into the C₄ ⁻ stream and the C₅ ⁺ stream in a debutanizer.
 4. The process of claim 3, wherein the C₄ ⁻ stream comprises an overhead stream from the debutanizer and the C₅ ⁺ stream comprises a bottoms stream from the debutanizer.
 5. The process of claim 1, wherein the hydrocarbon fraction from the reactor effluent is a C₃ ⁻ hydrocarbon fraction.
 6. The process of claim 4, wherein the C₃ ⁻ stream comprises the hydrocarbon fraction from the reactor effluent.
 7. The process of claim 6, wherein a C₂-C₄ stream exits the demethanizer and is fed to a deethanizer wherein C₂ hydrocarbon(s) are separated from the C₂-C₄ stream.
 8. The process of claim 7, wherein the C₂-C₄ stream exits as bottoms and the methane exits as overhead from the demethanizer.
 9. The process of claim 8, wherein C₃-C₄ stream exits the deethanizer and is fed to a depropanizer wherein C₃ hydrocarbon(s) are separated from the C₃-C₄ stream.
 10. The process of claim 9, wherein the C₃-C₄ stream exits as bottoms and the C₃ hydrocarbon(s) exit as overhead from the depropanizer.
 11. The process of claim 10, wherein C₄ hydrocarbon(s) are removed from the depropanizer as a stream that is recycled to the demethanizer as a portion of the absorber medium.
 12. The process of claim 1, wherein the hydrocarbon feedstream comprises naphtha.
 13. The process of claim 1, wherein the hydrocarbon feedstream is reacted in a catalytic cracker.
 14. The process of claim 12, wherein the hydrocarbon feedstream is reacted in a catalytic cracker.
 15. The process of claim 1, performed in the absence of ethylene refrigeration.
 16. The process of claim 12, performed in the absence of ethylene refrigeration.
 17. The process of claim 13, performed in the absence of ethylene refrigeration.
 18. The process of claim 4, wherein the overhead C₄ ⁻ stream is compressed and cooled before separation into the C₄ stream and the C₃ ⁻ stream.
 19. The process of claim 18, wherein the gaseous C₃ ⁻ stream is fed to the absorber demethanizer at a first location and the liquid C₄ strewn is fed to the absorber demethanizer at a second location which is above first location.
 20. The process of claim 1, wherein at least a second portion of the absorber medium comprises a C₄ hydrocarbon recycle stream from downstream processing.
 21. The process of claim 20, wherein the downstream processing comprises separation of the C₄ hydrocarbon from hydrocarbon mixture.
 22. The process of claim 21, wherein the separation of the C₄ hydrocarbon from a hydrocarbon mixture comprises separation in C₃-C₄ mixture.
 23. The process of claim 21, wherein the separation of the C₄ hydrocarbon from a hydrocarbon mixture comprises separation of C₂ from a C₂-C₄ hydrocarbon mixture and separation of the C₄ hydrocarbon from C₃-C₄ mixture.
 24. The process of claim 1, wherein hydrocarbon feedstream is reacted in a propylene catalytic cracker to produce the C₁-C₄ ⁺ reactor effluent.
 25. A process comprising: (i) catalytically cracking a hydrocarbon feedstream to produce an olefinic reactor effluent; (ii) fractionating the olefin reactor effluent in a primary fractionator into a primary fractionator overhead stream kind a primary fractionator bottoms stream; (iii) feeding the primary fractionator overhead stream to a debutanize, wherein the overhead stream is separated into a C₄ ⁻ overhead stream and a C₅ ⁺ bottoms stream; (iv) compressing and cooling the C₄ ⁻ overhead stream; (v) separating the compressed an cooled C₄ ⁻ overhead stream into a C4stream and a C₃ ⁻ stream; (vi) feeding the C₄ stream to a first location of an absorber demethanizer, vii) feeding the C₃ ⁻ stream to the absorber demethanizer at a C₃ ⁻ stream feed location that is below the first location; (viii) separating methane from C₃ ⁻ stream as overhead in the demethanizer; (ix) removing a C₂-C₄ stream from the demethanizer as bottoms; (x) feeding the C₂-C₄ stream from the demethanizer to a deethanizer, wherein the C₂-C₄ stream is separated into a C₂ overhead stream and a C₃-C₄ bottoms stream; (xi) feeding the C₃-C₄ bottoms stream to a depropanizer, wherein the C₃-C₄ bottoms stream is separated into a C₃ overhead stream and a C₄ bottoms stream; and (xii) feeding at least a portion of the C₄ bottoms stream to the absorber demethanizer at a location above the C₃-stream feed location.
 26. The process of claim 25, in the absence of ethylene refrigeration.
 27. The process of claim 25, wherein the hydrocarbon feedstream comprises naphtha.
 28. The process of claim 26, wherein the hydrocarbon feedstream comprises naphtha. 